Factors Driving 2015 U.S. Oil Output

Rig counts are a highly imperfect guide to future oil
production but they are one of the few readily available
statistics on oilfield activity so it is unwise to dismiss their
importance entirely.

The sharp drop in crude oil prices since June 2014 and associated
fall in rig counts published by state regulators and service
companies such as Baker Hughes has sparked a lively debate about
the short-term outlook for U.S. oil production.

Some analysts have forecast the drop in rig counts will cause
production to peak in the first six months of 2015 then begin to
fall in the second half of the year. I count myself in this camp.

Other analysts predict production will remain steady or continue
to grow, albeit much more slowly than the 1 million barrel per
day (bpd) increases recorded in 2013 and 2014.

In practice, the differences are smaller than the two sides
imply. Most forecasters put the change in daily production
between December 2014 and December 2015 at less than 250,000 bpd,
whether up or down.

For example, the U.S. Energy Information Administration (EIA)
predicts output in December 2015 will be just 90,000 bpd higher
than in December 2014 ("Short-Term Energy Outlook" Jan 2015).

That would be a marked slowdown from the 1.28 million bpd
increase between December 2013 and December 2014 or the 790,000
bpd increase between December 2012 and December 2013.

At a rough approximation, most forecasters expect U.S. production
to be flat in 2015 - after two years of 1 million bpd growth,
during which time North American shale producers were the
marginal suppliers to the world oil market.

And every forecast for U.S. oil production contains an implicit
forecast for what will happen to oil prices over the course of
the year.

EIA thinks the number of active drilling rigs in the United
States will fall by 24 percent between January and October 2015
before starting to recover in November.

That forecast is based on its assumption WTI prices will increase
to an average of $53 per barrel by June and $67 in December.

WTI prices have so far averaged just under $48 so far in 2015, so
EIA's forecasts for rig counts and production are conditioned on
a $20 price increase by the end of the year.

NOT JUST RIG COUNTS

U.S. oil production "reflects more than just the rig count," as
EIA emphasised in a research note published on Monday analysing
the combined effect of all the factors known to affect output.
The note is essential reading for anyone trying to understand the
likely production trend in 2015.

In fact, oil production reflects a constellation of factors, of
which the most important are:

1. The number of rigs employed (raw rig count).

2. The speed with which rigs are able to drill wells on average
(affected by the time lost moving location and setting up,
incidents causing stoppages and type of rock drilled through).

3. Efficiency and capability of the rigs (maximum operating depth
and available horsepower).

4. Average vertical depth of wells drilled and length of
horizontal sections.

5. Speed with which wells, once drilled, are pressure pumped and
completed, so they can start producing.

6. Quality of the rock in the neighbourhood of newly drilled and
completed wells, affecting production rates.

7. Average number of stages fractured in each well (which can
range from 10 to 30 or more).

8. Average production from the wells during the first 30 or 60
days and decline rates thereafter as natural energy in the
reservoir falls.

9. Decline rates on production from old wells (average age and
decline rates on the stock of existing wells drilled in both
shale plays and conventional oil fields).

10. Wellhead oil prices relative to the full life-cycle breakeven
costs of drilling new wells.

Rig counts are just one of many factors which determine
production. Experts are right to remind readers that production
is about much more than "just the rig count". In a sense every
well and every drilling team is different and the impact on
production is complicated. Some simplifications must, however, be
made for the sake of analysis.
COPING WITH A CRASH

In the face of a steep decline in oil prices, production
companies have a number of strategic options to cut costs and
improve recoveries.

The least-efficient rigs and crews can be idled first. The
remaining rigs can be pulled from exploration work in frontier
areas (where recoveries are uncertain) to focus on development
work and infill drilling in existing plays (where likely
production is more certain).

Within existing plays, rigs can be pulled back from the periphery
to concentrate the most high-yielding "sweet spots".

Production companies can negotiate and likely obtain big
reductions in hire rates for rigs and pressure pumping equipment
as well as the price of all their other inputs, from water and
sand to diesel and trucking.

For all these reasons, the number of new wells and the output
from them is likely to fall more slowly than the rig count.

At the same time, breakeven prices for new wells will come down
substantially to reflect cheaper drilling and pressure pumping
costs.

In some instances, however, producers may postpone the completion
of already drilled wells to defer the costs and hope for a
recovery in prices.

Completion accounts for two-thirds of the total cost of some of
the very long horizontal wells now being developed. And one third
of the well's total production may occur in the first 12 months.
So there are sharp financial incentives to slow completion where
possible.

There is a substantial backlog of oil wells that were drilled in
2014 waiting for the arrival of pressure pumping crews and other
completion services. U.S. production could continue rising for
several more months as these wells are finished and put into
production.

But there are also anecdotal reports from oilfields that some
completions are being postponed to save costs and wait for a more
favourable price environment. If widespread, slower completions
could cause production to peak earlier than expected.

DATA AVAILABILITY BIAS

While production forecasts are about much more than just rig
counts, rig counts are one of the few pieces of data readily
available in near real-time. There is no comprehensive and timely
information on drilling speed, well depth and horizontal length,
initial production rates, and decline rates on the stock of
existing wells.

There is some information on the number of new wells started
("spudded") each month but that is only marginally more helpful
than a rig count because production depends on where the wells
are located and how many horizontal stages are fractured, among
other factors.

Focusing on the rig count introduces a data availability bias
into production forecasts. But since it is almost the only
comprehensive and timely information on drilling activity,
forecasters do not have much choice. Rig count data must be
interpreted carefully but it would be unwise to ignore it
completely.

On balance, the safest conclusion is that U.S. shale producers
will be able to offset some of the fall in oil prices by drilling
more efficiently, and that the amount of new oil produced per rig
employed can be increased.

But the efficiency improvements are unlikely to fully offset the
decline in prices and rig counts, at least in the short term.

For that reason, it seems reasonable to assume U.S. shale
production will be fairly flat in 2015, give or take a couple of
hundred thousand barrels per day, after several years of
exceptional growth.